| 序号 | 专利名 | 申请号 | 申请日 | 公开（公告）号 | 公开（公告）日 | 发明人 |
|---|---|---|---|---|---|---|
| 181 | 밸브 장치 | KR1020137016449 | 2011-11-24 | KR1020140030106A | 2014-03-11 | 휴즈짐; 파커데일 |
| 본 발명은, 일반적으로, 웰(well)로부터의 유체의 흐름을 제어하기 위한 밸브 장치에 관한 것이다.
본 발명인 웰용 밸브 장치(100)는 밸브 바디(101)와 밸브 부재(102)를 포함한다. 밸브 바디(101)는, 밸브 바디(101)를 관통하여 연장되는 제1 통로(190)와, 제1 통로(190)로부터 횡방향으로 밸브 바디를 관통하여 연장되는 적어도 하나의 제2 통로(193)를 포함한다. 밸브 바디(101)를 웰에 연결하여, 웰로부터의 유체가 제1 통로에 흐르게 할 수 있다. 밸브 부재(102)를 제1 통로(190)에 삽입하고 밸브 바디(101)에 대하여 이동시켜, 제1 통로(190)로부터 각각의 제2 통로(193) 내로의 유체 흐름을 제어할 수 있다. |
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| 182 | 一种液压控制多次开关阀及其定位工具 | CN201120089349.9 | 2011-03-30 | CN202023535U | 2011-11-02 | 刘巾 |
| 本实用新型公开了一种液压控制多次开关阀，该开关阀包括两根同轴连接在一起的上中心管与下中心管，管外配合套装着活塞滑套，活塞滑套与下中心管之间构成相互密封隔开的进、出液室，活塞滑套与上中心管的中部管壁上分别设置着滑套循环孔以及循环孔；用以对所述液压控制多次开关阀进行定位的定位工具，包括定位接头以及定位器，所说的定位接头为在下中心管的下端连接着一短节，短节中部内周壁上具有一环形凹槽，所说的定位器配合套装在所说的短节内，定位器上的嵌瓦上下端面分别与短节内凹槽的上部内壁以及下部内壁相配合接触。本实用新型可用于油田直井特别是水平井的找隔水管柱及多功能完井管柱。 | ||||||
| 183 | LINER HANGER RUNNING TOOL AND METHOD | EP10810358.1 | 2010-07-29 | EP2467562B1 | 2018-12-05 | YOKLEY, John M.; WHITE, Pat M.; GRAHAM, Tommie J., Jr. |
| A liner hanger running tool (10) and method are provided for positioning a liner in a well bore. A tool mandrel (24) is supported from a running string, and a housing (44) surrounds the tool mandrel. A flow annulus between the mandrel and the housing allows fluid to pass upward through the running tool to a position above the liner. A hydraulic release mechanism (78, 79) is activated by fluid pressure within the mandrel to axially move a piston (50) positioned radially outward of the mandrel to release the running tool from the liner. | ||||||
| 184 | A METHOD FOR INDIVIDUALLY SERVICING A PLURALITY OF ZONES OF A SUBTERRANEAN FORMATION | EP18179750.7 | 2012-02-10 | EP3404200A1 | 2018-11-21 | Howell, Matthew Todd |
A method of individually servicing a plurality of zones (150) of a subterranean formation comprising: |
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| 185 | VANNE DE CONTRÔLE DE DÉBIT COMPRENANT UNE PLURALITÉ DE TUBES À SECTION GÉOMÉTRIQUEMENT VARIABLE | EP14830846.3 | 2014-12-19 | EP3084118B1 | 2018-08-01 | JOUENNE, Stéphane; HEURTEUX, Guillaume |
| 186 | APPARATUS, SYSTEMS AND METHODS FOR MULTI-STAGE STIMULATION | EP16766206.3 | 2016-09-06 | EP3344848A1 | 2018-07-11 | FACCA, Lewis; STYLER, Graham; SUSHKO, Andrew; TAIT, William; RADMANOVICH, D.j.; BELLAVANCE, Mike |
| Embodiments of a sleeve assembly, used for stimulating multiple stages in a completion string has a lower shifting sleeve and an upper shifting sleeve and stimulation ports formed therebetween. The sleeves are caused to shift by progressively larger objects pumped through a bore of the completion string and engaging seats formed thereon. The seat on the lower sleeve is a releasable seat. When shifted the lower sleeve opens the stimulation ports. The seat on the upper sleeve is sized to accept the same size object as is required to engage and shift the lower sleeve on the stage uphole therefrom to close the ports. Thereby, stimulation ports are opened and closed without increasing a number of objects required to stimulate the wellbore. Further, as the ports at each stage below the stage being stimulated are closed, the objects are not required to isolate the bore therebelow. | ||||||
| 187 | FRACKING VALVE | EP15845984 | 2015-10-01 | EP3201425A4 | 2018-05-16 | SARGENT SHANE; MCCARTHY MATTHEW |
| An apparatus for selectably isolating a subterranean formation from a production string comprises a radially expandable ring located between upper and lower sleeves and retained at a position to intrude into a central passage extending therethrough. The expandable ring is permitted to radially expand into a recess upon displacement of the lower sleeve to permit a body retained thereon to move therepast. The apparatus includes a pair of inner and outer indexing rings which cooperate to permit the inner and outer indexing rings to move towards a bottom end thereof only to a fixed endwall whereafter further movement of the inner and outer indexing rings and lower sleeve is prevented. | ||||||
| 188 | WELL BARRIER | EP11713500.4 | 2011-03-10 | EP2545247B1 | 2018-05-02 | EDWARDS, Jeffrey |
| A well barrier for sealing a downhole conduit is described. The well barrier comprises a housing defining a throughbore having a longitudinal axis, a valve actuator and a flapper valve. The flapper valve includes a flapper attached to the valve actuator. The flapper valve and the valve actuator are axially movable with respect to the housing in a direction parallel to the longitudinal axis. The flapper is adapted to move from one of a throughbore open and throughbore closed positions to the other of said open and closed positions when the actuator and flapper valve move a predetermined axial distance. | ||||||
| 189 | RE-FRACTURE APPARATUS AND METHOD FOR WELLBORE | EP14793737.9 | 2014-10-24 | EP3060744B1 | 2018-04-11 | WILLIAMSON, Scott; VALKENBURG, Comelis |
| Re-treatment of a formation having a wellbore, which can be an open hole or a cased hole lined with casing, involves deploying a tubing string in the casing having tools disposed at intervals thereon. The tools position on the tubing string, and the tubing string with the tools thereon is inserted into the casing. Biasing rings of the tools passively engage with the casing. The annulus is accessed between the tubing string and the casing at the intervals between the tools. For example, sliding sleeves on the tubing string can be opened (selectively), or new plug and perforation operations can be used to create perforations in the tubing string at desired intervals between the tools. With access achieved, retreatment is pumped down the tubing string, out the access to the annulus, and at least partially sealed by the engaged rings in the intervals between the tools. | ||||||
| 190 | REMOTELY OPERATED ISOLATION VALVE | EP17193142.1 | 2011-09-20 | EP3290632A1 | 2018-03-07 | NOSKE, Joe; SMITH, Roddie R.; SMITH, Paul L.; BAILEY, Thomas F.; MCDOWELL, Christopher L. |
A method of operating an isolation valve in a wellbore includes: deploying a work string into the wellbore through a tubular string disposed in the wellbore. The work string comprises a deployment string, a shifting tool, and a bottomhole assembly (BHA). The tubular string comprises the isolation valve and an actuator. The method further includes rotating the actuator using the shifting tool, thereby opening or closing the isolation valve. The isolation valve isolates a formation from an upper portion of the wellbore in the closed position.
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| 191 | DOWNHOLE SEALING AND ACTUATION | EP16720538.4 | 2016-04-29 | EP3289168A1 | 2018-03-07 | CHURCHILL, Andrew Philip |
| A downhole tool comprises a hollow body having a wall and a port in the wall, and a closing sleeve movable relative to the body to open and close the port. A seal is provided between the body and the sleeve and is configured to hold differential pressure. An isolation member may be deployed in the tool to isolate the seal from differential pressure and close the port. The isolation member may be deployed following initiation of a tool activation process, a successful outcome of the process being translating the closing sleeve and closing the port, and positioning the seal to hold a differential pressure. If it is detected that the outcome has not been achieved, the isolation member is deployed to isolate the seal from differential pressure and close the port. | ||||||
| 192 | Burst sleeve and positive indication for fracture sleeve opening | EP14196403.1 | 2014-12-04 | EP2881536B1 | 2018-01-31 | TOUGH, John; VINSON, Justin P; BLANTON, Eric M; SHAFFER, Raymond; RICHEY, Luke V |
| A downhole tool, such as a sliding sleeve, deploys on a tubing string in a borehole. The tool has a housing with an internal bore and at least one port communicating outside the housing. An insert disposed in the bore can move from a closed position to an opened position relative to the port so fluid can be communicated to the borehole. A burst band disposed outside the housing at the port can break away from the housing in response to a particular pressure level communicated through the open port. In particular, the insert can have a seat that engages a deployed plug or ball. The insert shifts open when a first level of applied pressure against the seated ball shears the insert free. This can give a first indication that the insert has moved open. Then, a second level of pressure can be detected when the burst band breaks as a second indication that the insert is opened. | ||||||
| 193 | CHOKE | EP17188254.1 | 2014-06-09 | EP3272997A2 | 2018-01-24 | Purkis, Daniel |
A fluid flow control system for downhole use in an oil or gas well has a choke with a conduit having an inlet and an outlet, and a flow restrictor comprising first and second choke members 10,20, one of which rotates relative to the other to choke or promote flow. The first and second choke members 10,20 are axially spaced from one another, and have mating faces that are optionally planar, and are axially stacked in the choke. The choke is operated by a shifting tool 50, which grips the inner surface of the rotating choke member 10, and rotates it relative to the other 20, in order to vary the flow. The shifting tool 50 is adapted to be deployed on a line or string of tools passing through the bore of the choke.
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| 194 | METHOD AND VALVE ASSEMBLY FOR FLUSHING OF DEBRIS | EP16708131.4 | 2016-03-03 | EP3265646A1 | 2018-01-10 | BRAATEN, Knut, Roar |
| The invention concerns a method for flushing of debris from a valve assembly arranged in a fluid line. The valve assembly comprises at least two flow regulating units arranged in series between an inlet and an outlet of the valve assembly. The inlet pressure is larger than the outlet pressure, and each flow regulating unit has a spring element and an opening is provided for each flow regulating unit which initially is set as a minimum opening allowing fluid to pass from one side of the each of the flow regulation unit to the other side of the flow regulation unit. The spring element regulates the opening in response to the pressure difference over the flow regulating unit. The method comprises the following steps in the case when at least one of the openings clogs: —equalizing the pressure over the other flow regulating unit(s) downstream and upstream to the clogged opening thereby—providing a pressure difference across the flow regulating unit where clogging occurs, which pressure difference exceeds the spring force and increases the opening for this flow regulating unit for flushing the debris. The invention also concerns a valve assembly, a use of the valve assembly and a fluid injection valve assembly. | ||||||
| 195 | IMPROVED WIRELINE DRILLING SYSTEM | EP12809303.6 | 2012-11-28 | EP2807324B1 | 2018-01-10 | WESSEL, Roland |
| A wireline drilling system for the hydrocarbon exploration and production industry incorporating a drilling cuttings removal system which acts to remove and store cuttings displaced by a drill bit during drilling operations. The cuttings removal system may employ a screw member having a tapered lower portion and a narrow upper portion to transport drilling cuttings to a cuttings basket and distribute the cuttings therein. Embodiments of the invention include an integral tractor to progress the wireline drilling system and provide weight-on-bit, as well as assist in retrieval of the wireline drilling system if the tool should become stuck. | ||||||
| 196 | FRACTURING METHOD USING IN SITU FLUID | EP16174908.0 | 2016-06-17 | EP3258057A1 | 2017-12-20 | KRÜGER, Christian |
The present invention relates to a fracturing method for providing fractures in a formation downhole for optimising hydro-carbon production in a well having a well tubular metal structure comprising several self-closing flow assemblies, each self-closing flow assembly comprising a sleeve which is movable along a longitudinal axis of the well tubular metal structure for opening or closing a port in the well tubular metal structure. The method comprises providing fracturing fluid derived from hydro-carbons; submerging an activation device into the well tubular metal structure; pressurising the well tubular metal structure by means of the fracturing fluid for moving the activation device towards a first self-closing flow assembly; engaging the sleeve of the first self-closing flow assembly by means of the activation device; further pressurising the well tubular metal structure by means of the fracturing fluid for moving the sleeve of the first self-closing flow assembly and thereby opening the port; injecting the fracturing fluid through the port of the first self-closing flow assembly for providing fractures in the formation; decreasing a pressure of the fracturing fluid by 0.5-20% for releasing the activation device from the first self-closing flow assembly, thereby closing the port; and moving the activation device by means of pressurised fracturing fluid for engaging a second self-closing flow assembly.
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| 197 | UNDERBALANCE ACTUATORS AND METHODS | EP13803805.4 | 2013-06-11 | EP2859181B1 | 2017-12-13 | CAMINARI, Richard T. |
| An actuation method according to one or more embodiments includes axially translating an operator in a first direction in response to applying a tubing pressure to a first side in excess of an annulus pressure acting on a second side, axially translating the operator in a second direction to an actuation position in response to applying an underbalance pressure level to the operator and operating a tool element from a first position to a second position in response to translating the operator to the actuation position. | ||||||
| 198 | PLUGGING OF A FLOW PASSAGE IN A SUBTERRANEAN WELL | EP14889493 | 2014-04-16 | EP3105409A4 | 2017-12-06 | MURPHREE ZACHARY R; FRIPP MICHAEL L; WALTON ZACHARY W |
| 199 | TUBULAR ACTUATING SYSTEM AND METHOD | EP12773759.1 | 2012-04-19 | EP2699760B1 | 2017-11-22 | KING, James G. |
| A tubular actuating system includes a plurality of series of actuators disposed within a tubular with at least one of the series having a plurality of actuators. Each of the plurality of actuators in the at least one of the series is alterable from a first position allowing passage of plugs below a selected size to a second position allowing actuation by plugs of selected sizes. The plurality of actuators of the series are distributed within the tubular such that the more upstream of any two of the plurality of actuators is actuatingly engagable with a larger one of the plugs than the more downstream of the two of the plurality of actuators when in the second position, and the plurality of series is distributed such that for any two of the series the more upstream of the two series requires a larger plug to alter the actuators therewithin. | ||||||
| 200 | WELLBORE FRAC TOOL WITH INFLOW CONTROL | EP11826241 | 2011-09-12 | EP2619404A4 | 2017-11-15 | THEMIG DANIEL JON |
